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Copyright © SEL 2008
Synchrophasor-Based Monitoring, Analysis, and Control
Roy Moxley Schweitzer Engineering Laboratories, Inc.
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The Power System Is Changing
Photo Courtesy of Shawn Jacobs, OG&E
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‘02 ’03 8/03 ‘05 ‘06 ’06 ’07 ’07+
Synch
roph
asor
s in a
Mete
r
Synch
roph
asor
s on t
he W
eb
IEEE P
rotoc
ol in
a Rela
y
Synch
roph
asor
s in a
Rela
y
Retrofi
t Syn
chro
phas
ors
In a R
elay
Utility
Grade
PDC
SCADA Syn
chro
phas
ors
Real-T
ime C
ontro
l in
a Rela
y (Mex
ico)
SEL Synchrophasor Vision
0
5
10
15
20
25
AG10AB10BCG10ABC10
AG50AB50BCG50ABC50
AG80AB80BCG80ABC80
AG90AB90BCG90ABC90
Fault Type and Distance
Tim
e (m
s)
Local side trip times WITHOUT synchrophasors Local side trip times WITH synchrophasors
Real-T
ime V
ecto
r
Proce
ssor
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Synchrophasors Are StandardSEL-421
IEEE C37.118
SEL-451SEL-487ESEL-787SEL-734 SEL Fast Message
SEL-311A, B, CSEL-311LSEL-351SEL-351SSEL-351A
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Protection AND Synchrophasors
0
5
10
15
20
25
AG90AB90BCG90ABC90
AG50AB50BCG50ABC50
AG20AB20BCG20ABC20
AG10AB10BCG10ABC10
Fault Type and Distance
Tim
e (m
s)
Remote side trip times WITHOUT synchrophasors Remote side trip times WITH synchrophasors
0
5
10
15
20
25
AG10AB10BCG10ABC10
AG50AB50BCG50ABC50
AG80AB80BCG80ABC80
AG90AB90BCG90ABC90
Fault Type and Distance
Tim
e (m
s)
Local side trip times WITHOUT synchrophasors Local side trip times WITH synchrophasors
Synchrophasors do not hurt relay performance
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Relaying Has No Impact on PMCU Function
No lostdata
4 4.1 4.2 4.3 4.4 4.5 4.6 4.7 4.8 4.90
1
2
3
Local bus side phase A voltage synchrophasorSynchrophasor data check
Time (s)
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Relays Are Right for Synchrophasors
Phasor measurement and control unit(PMCU) ≥ PMU
Minimal incremental cost
Reduced current and voltage connections
High-accuracy measurements
High reliability and availability
Future control applications
Relays are everywhere
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SEL Synchrophasor Equipped Devices Worldwide !
North AmericaNorth America>20,000 units>20,000 units
South AmericaSouth America>2,000 units>2,000 units
Europe/AsiaEurope/Asia>3,000 units>3,000 units
Africa/Middle EastAfrica/Middle East>1,000 units>1,000 units
Asia Asia PacificPacific
>5,000 units>5,000 units
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Application Options – Not “One Size Fits All”
SEL-5078 Visualization
SEL-5077, SEL-5078 Archiving
System Operator, Reliability Council
SEL-3306 Hardware PDC SEL-5077 Software PDC
SEL-3378 Vector Processor
PMU’s
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Protection and Control Time Frame
~1.0 Second ~30 Seconds
Relay Action Human ActionControl Action
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METER PM 13:22
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Monitor a Gen Drop Test (New Zealand)
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49.1
49.3
49.5
49.7
49.9
50.1
50.3
Timestamp 5/3/2007 3:10:18.6805/3/2007 3:11:06.6805/3/2007 3:11:54.6805/3/2007 3:12:42.6805/3/2007 3:13:30.6805/3/2007 3:14:18.6805/3/2007 3:15:06.680
Whakamaru_Frequency Huntly_Frequency
Test Shows System Remains Stable When 400 MW Dropped
Frequency recordings at both ends perfectly overlap and align in time.
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Malin – Round Mt. 500 kV Trips June 18, 2007
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“The MRI of Power Systems”
NERC press release on Florida outage
Feb. 26, 2008:
Synchrophasors are “Like the MRI of bulk power
systems”
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Synchrophasor-Based Control – Now a Reality
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Big Creek Controls Rector Static VAR Compensator
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SCE Uses C37.118 From Relays and PMU
SCADAMaster
DNP3
IEEE C37.118
InformationProcessor
(Harris 5000/6000, IEC 60870-103, Modbus, SEL Fast Message, SES 92, Telegyr 8979, Conitel 2020, GETAC, Recon 1.1, CoDeSys, OPC, …)
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Impact of the Rector SVC: 6-14-07 (pre-SVC) vs. 8-30-07 (post-SVC)
Magunden Substation Voltage Comparison(Rector Substation Events 6-14-07 and 8-30-07)
220
222
224
226
228
230
232
234
236
238
240
-5.00 0.00 5.00 10.00 15.00 20.00 25.00
Time (seconds)
Mag
unde
n Vo
ltage
(kV)
Rector 8-30-2007 event (POST-SVC) Rector 6-14-2007 event (PRE-SVC)
The Rector SVC had the apparent effect of reducing the magnitude & duration of the fault-induced slow voltage
recovery…
6-14-2007 (pre-SVC)
8-30-2007 (post-SVC)
NOTE: Voltages shown were measured ~70 miles south of Rector Substation (actual low voltage event was of greater
magnitude at Rector substation itself)
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Effect of SVC Operation on Big Creek Before -
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Effect of SVC Operation on Big Creek After -
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Synchronous Vector ProcessingSystem
MeasurementFunction
CalculationOutput
Designation
Send Control to System(Application)
f(x)
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Apply the
Collect synchronous phasor measurements
Collect logical inputs
Perform vector and scalar math
Make decisions
Produce outputs
Report data
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Select Quantities From Each PMU
PMU1PMU2PMU3
Analogs| V1 |∠V1
| I1 |∠I1
FreqPSV42TE (time error)
Binary dataStatusTriggers
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Integrate Wide-Area Protection and Control
Static Var Control
SEL-421
SEL-421
SEL-421
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Apply Flexible Function Calculations
IEC 61131 engineMathTrigDifferentials
Preprogrammed blocksPowerAngle differenceModal analysisStation topology check
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Combine Pre-Configured with Custom Functions
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Provides Function Blocks
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Map PMU Quantities to Phase Angle Difference Monitor
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Improve Local Measurements
V A
Substation State and Topology Processor
Refined Is, Vs, Alarms,
and Topology52
52
52
52 52 52
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Identify and Quarantine Bad Data
Measurements Measurements+
Calculate Median
Measurements+
Calculate Median+
Flag and Quarantine
Set Flag
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Line Trip…Stable
System Separation
Line Trip and Generation
Loss…Unstable
Real-Time Modal Analysis Monitor Predicts System Disturbances
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Use Oscillation Frequency and Damping Ratio
For the complex Eigen value pair:
Oscillation frequency is:
Damping ratio is:
djω±σ=λ
πω
=2
f dosc
d
i
ωσσς+
=2
–2
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Modal Analysis Shows System Response
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Develop Custom ApplicationsVoltage Collapse Detection
Instability of Distributed Generation
Complex Power Swings
Others ?
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Operating Point
Bifurcation Point
Utilities Are Operating Closer to the Edge
PU Nominal Load
Operating Point
Bifurcation Point
MarginMargin
1.61.51.31.00.0
0.5
1.0
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Long Island: Monitor Angles Between Transmission Distribution Buses to Detect and Prevent Voltage Collapse
( )X)θcos(2V)θsin(1S 2
2s
max−=
S = P + jQ
ZL = R + jX
δ∠rV
0VS ∠
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Calculate Voltage Stability Index (VSI)
SVP calculates maxima: P, Q, and S
Calculate margins:
QQQ maxmargin −=
⎟⎠
⎞⎜⎝
⎛=
max
margin
max
margin
max
margin
SS
,PP
minVSI
PPP maxginmar −=
SSS maxmargin −=
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Improve Power Swing Detection
Actual Swing from 2003 Blackout
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Wide-Area Measurement Is Better than Traditional “Blinder” Methods
Impedance Loci
Wide-Area Measurement
Replace and improve on local out of step
What if load or source impedance changes?
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Delta/Delta-Dot Phase Plane Analysis
-20 0 20 40 60 80 100 120 140 160 180-200
-100
0
100
200
300
400
500
Angle Difference δ (deg)
Slip
(de
g/se
c)
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Delta-Dot Delta-Doubledot Phase Plane
0 0.5 1 1.5 2 2.5 3 3.5 4-40
-30
-20
-10
0
10
20
30
40
Slip (Hz)
Acc
eler
atio
n (H
z/se
c)
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Use Fast Operate Control Blocks for Closed-Loop Control
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Synchrophasors Are StandardSEL-421
IEEE C37.118
SEL-451SEL-487ESEL-787SEL-734 SEL Fast Message
SEL-311A, B, CSEL-311LSEL-351SEL-351SSEL-351A
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Synchrophasors Provide New and Improved Capabilities
Angle measurement
Disturbance analysis
Modal analysis
Out-of-step detection
Real-time control
What Else Can They Do For You?
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Thank You!Thank You!